U.S. patent number 10,329,892 [Application Number 15/343,535] was granted by the patent office on 2019-06-25 for cross-plot engineering system and method.
This patent grant is currently assigned to Petrolink International Ltd.. The grantee listed for this patent is Petrolink International Ltd.. Invention is credited to Rafael Angel Bermudez Martinez.
United States Patent |
10,329,892 |
Bermudez Martinez |
June 25, 2019 |
Cross-plot engineering system and method
Abstract
In one embodiment, a method includes facilitating a real-time
cross-plot display of drilling-performance data for a current well.
The real-time cross-plot display includes a plurality of data plots
represented on a common graph such that each data plot specifying
at least two drilling parameters. Each data plot includes a
plurality of data points such that each data point is expressable
as Cartesian coordinates in terms of the at least two drilling
parameters. The method further includes receiving new channel data
for the current well from a wellsite computer system. In addition,
the method includes creating, from the new channel data, new data
points for the plurality of data plots as the new channel data is
received. Moreover, the method includes updating the plurality of
data plots with the new data points as the new data points are
created.
Inventors: |
Bermudez Martinez; Rafael Angel
(Houston, TX) |
Applicant: |
Name |
City |
State |
Country |
Type |
Petrolink International Ltd. |
Douglas |
N/A |
IM |
|
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Assignee: |
Petrolink International Ltd.
(Douglas, IM)
|
Family
ID: |
57399824 |
Appl.
No.: |
15/343,535 |
Filed: |
November 4, 2016 |
Prior Publication Data
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Document
Identifier |
Publication Date |
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US 20170051601 A1 |
Feb 23, 2017 |
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Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
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14018298 |
Sep 4, 2013 |
9512707 |
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13919240 |
Jun 17, 2013 |
9518459 |
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61660565 |
Jun 15, 2012 |
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61697687 |
Sep 6, 2012 |
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B
47/00 (20130101); E21B 47/024 (20130101); E21B
45/00 (20130101); E21B 44/00 (20130101); E21B
49/08 (20130101); E21B 49/00 (20130101); G06T
11/206 (20130101) |
Current International
Class: |
E21B
47/00 (20120101); G06T 11/20 (20060101); E21B
49/00 (20060101); E21B 49/08 (20060101); E21B
47/024 (20060101); E21B 45/00 (20060101); E21B
44/00 (20060101) |
References Cited
[Referenced By]
U.S. Patent Documents
Other References
McLaren et al., Improving the Value of Real-Time Drilling Data to
Aid Collaboration, Drilling Optimization, and Decision Making, Nov.
11-14, 2007, 2007 SPE Annual Technical Conference and Exhibition,
Anaheim, CA, 13 pp. cited by examiner .
U.S. Appl. No. 15/446,761, Gonzalez. cited by applicant .
U.S. Appl. No. 13/829,590, filed Sep. 26, 2013, Abraham et al.
cited by applicant .
U.S. Appl. No. 13/919,240, filed Dec. 13, 2016, Bermudez Martinez
et al. cited by applicant .
U.S. Appl. No. 14/018,298, filed Dec. 6, 2016, Bermudez Martinez.
cited by applicant .
U.S. Appl. No. 14/820,955, filed Mar. 12, 2015, Abraham et al.
cited by applicant .
U.S. Appl. No. 14/477,444, Bermudez Martinez. cited by applicant
.
U.S. Appl. No. 15/343,836, filed Feb. 23, 2017, Bermudez Martinez
et al. cited by applicant .
Halliburton / Landmark Software & Services, "Drillworks.RTM.
User Guide", Oct. 2009. cited by applicant .
Martinez, R.B., Petrolink Services, Inc., and Olan, C.I., Petrolink
Services, Inc., "Improving Real-Time Drilling Optimization Applying
Engineering Performance From Offset Wells." SPWLA 53rd Annual
Logging Symposium, Jun. 16-20, 2012. cited by applicant .
Khudiri, M.M. and Shehry, M.A., Saudi Aramco, and Curtis, J.D.,
Petrolink International, "Data Architecture of Real-Time Drilling
and Completions Information at Saudi Aramco;" SPE 116848, 2008 SPE
Russian Oil & Gas Technical Conference and Exhibition, Moscow,
Russia, Oct. 28-30, 2008. cited by applicant .
Perez-Tellez, C., Rodriguez, R., and Ramirez, I., PEMEX Drilling
Business Unit, and Berm dez-Martinez, R.A., and Palavicini-Cham,
C.A., Petrolink Services Inc., "Applying a Real-Time Engineering
Methodology to Drill Ahead of Potential Undesirable Events;" OTC
23180, Offshore Technology Conference, Houston, Texas, USA, Apr.
30-May 3, 2012. cited by applicant.
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Primary Examiner: Le; Toan M
Attorney, Agent or Firm: Winstead PC
Parent Case Text
CROSS-REFERENCE TO RELATED APPLICATIONS
This patent application is a continuation of U.S. patent
application Ser. No. 14/018,298, filed on Sep. 4, 2013, now U.S.
Pat. No. 9,512,707. U.S. patent application Ser. No. 14/018,298 is
a continuation-in-part of U.S. patent application Ser. No.
13/919,240, filed on Jun. 17, 2013, now U.S. Pat. No. 9,518,459.
U.S. patent application Ser. No. 13/919,240 claims priority from
U.S. Provisional Application No. 61/660,565, filed on Jun. 15,
2012. U.S. patent application Ser. No. 14/018,298 claims priority
from U.S. Provisional Application No. 61/697,687, filed on Sep. 6,
2012. U.S. patent application Ser. No. 14/018,298, U.S. patent
application Ser. No. 13/919,240, U.S. Provisional Application No.
61/660,565, and U.S. Provisional Application No. 61/697,687 are
hereby incorporated by reference in their entirety.
Claims
What is claimed is:
1. A method comprising: on a central computing system comprising a
server computer, collecting channel data in real-time as the
channel data is generated, the channel data comprising measured
physical properties determined by sensors in use at a site of a
current well; the central computing system providing, over a
network interface, a real-time cross-plot display for the current
well; wherein the real-time cross-plot display comprises a
drilling-performance data plot and a drilling-event data plot;
wherein the drilling-performance data plot and the drilling-event
data plot each comprise a plurality of data points determined in
real-time over a progression of time as the channel data is
received; in real-time as the channel data is received, the central
computing system: creating, via the channel data, a new
drilling-performance data point for the drilling-performance data
plot; populating the drilling-performance data plot with the new
drilling-performance data point as the new drilling-performance
data point is created; detecting, via the channel data, a drilling
event based, at least in part, on a specified condition defining
the drilling event; responsive to a determination that the
specified condition defining the drilling event is met, creating,
via the channel data and the detected drilling event, a new
drilling-event data point for the drilling-event data plot;
populating the drilling-event data plot with the new drilling-event
data point as the new drilling-event data point is created; and
updating the provided real-time cross-plot display with the
populated drilling-performance data plot and the populated
drilling-event data plot.
2. The method of claim 1, comprising, as the channel data is
received, the central computing system: retrieving input data
comprising historical drilling-performance data for an offset well
relative to the current well, wherein the historical
drilling-performance data comprises a drilling event for the offset
well; updating the provided real-time cross-plot display with the
drilling event of the offset well; and generating an alert
responsive to determination that a measured depth for the current
well is within a preconfigured distance of a depth at which the
drilling event of the offset well occurred.
3. The method of claim 1 comprising, as the channel data is
received, the central computing system: retrieving input data
comprising historical drilling-performance data for an offset well
relative to the current well, wherein the historical
drilling-performance data comprises geopressure analysis data for
the offset well; computing data for the current well based on the
channel data; and updating the provided real-time cross-plot
display with the computed data for the current well.
4. The method of claim 3, wherein the real-time cross-plot display
comprises a comparative display of the historical
drilling-performance data for the offset well and
drilling-performance data for the current well relative to
depth.
5. The method of claim 3, wherein the computed data comprises pore
pressure.
6. The method of claim 5, wherein: the input data comprises
resistivity data for the offset well; the channel data comprises
resistivity data for the current well; and the computing comprises
computing the pore pressure using the resistivity data for the
current well and the resistivity data for the offset well.
7. The method of claim 5, wherein the computed data comprises a
fracture gradient.
8. The method of claim 7, wherein the retrieving comprises
retrieving at least a portion of the input data from settings
maintained by a calculation engine resident on the central
computing system.
9. The method of claim 8, wherein the at least a portion of the
input data comprises at least one of a matrix stress coefficient
and a Poisson ratio.
10. A system comprising a processor and memory, wherein the
processor and memory in combination are operable to implement a
method comprising: collecting channel data in real-time as the
channel data is generated, the channel data comprising measured
physical properties determined by sensors in use at a site of a
current well; providing a real-time cross-plot display for the
current well; wherein the real-time cross-plot display comprises a
drilling-performance data plot and a drilling-event data plot;
wherein the drilling-performance data plot and the drilling-event
data plot each comprise a plurality of data points determined in
real-time over a progression of time as the channel data is
received; in real-time as the channel data is received: creating,
via the channel data, a new drilling-performance data point for the
drilling-performance data plot; populating the drilling-performance
data plot with the new drilling-performance data point as the new
drilling-performance data point is created; detecting, via the
channel data, a drilling event based, at least in part, on a
specified condition defining the drilling event; responsive to a
determination that the specified condition defining the drilling
event is met, creating, via the channel data and the detected
drilling event, a new drilling-event data point for the
drilling-event data plot; populating the drilling-event data plot
with the new drilling-event data point as the new drilling-event
data point is created; and updating the provided real-time
cross-plot display with the populated drilling-performance data
plot and the populated drilling-event data plot.
11. The system of claim 10, the method comprising, as the channel
data is received: retrieving input data comprising historical
drilling-performance data for an offset well relative to the
current well, wherein the historical drilling-performance data
comprises a drilling event for the offset well; updating the
provided real-time cross-plot display with the drilling event of
the offset well; and generating an alert responsive to
determination that a measured depth for the current well is within
a preconfigured distance of a depth at which the drilling event of
the offset well occurred.
12. The system of claim 10, the method comprising, as the channel
data is received: retrieving input data comprising historical
drilling-performance data for an offset well relative to the
current well, wherein the historical drilling-performance data
comprises geopressure analysis data for the offset well; computing
data for the current well based on the channel data; and updating
the provided real-time cross-plot display with the computed data
for the current well.
13. The system of claim 12, wherein the real-time cross-plot
display comprises a comparative display of the historical
drilling-performance data for the offset well and
drilling-performance data for the current well relative to
depth.
14. The system of claim 12, wherein the computed data comprises
pore pressure.
15. The system of claim 14, wherein: the input data comprises
resistivity data for the offset well; the channel data comprises
resistivity data for the current well; and the computing comprises
computing the pore pressure using the resistivity data for the
current well and the resistivity data for the offset well.
16. The system of claim 14, wherein the computed data comprises a
fracture gradient.
17. The system of claim 16, wherein the retrieving comprises
retrieving at least a portion of the input data from settings
maintained by a calculation engine resident on the system.
18. The system of claim 17, wherein the at least a portion of the
input data comprises at least one of a matrix stress coefficient
and a Poisson ratio.
19. A computer-program product comprising a non-transitory
computer-usable medium having computer-readable program code
embodied therein, the computer-readable program code adapted to be
executed to implement a method comprising: collecting channel data
in real-time as the channel data is generated, the channel data
comprising measured physical properties determined by sensors in
use at a site of a current well; providing, over a network
interface, a real-time cross-plot display for the current well;
wherein the real-time cross-plot display comprises a
drilling-performance data plot and a drilling-event data plot;
wherein the drilling-performance data plot and the drilling-event
data plot each comprise a plurality of data points determined in
real-time over a progression of time as the channel data is
received; in real-time as the channel data is received: creating,
via the channel data, a new drilling-performance data point for the
drilling-performance data plot; populating the drilling-performance
data plot with the new drilling-performance data point as the new
drilling-performance data point is created; detecting, via the
channel data, a drilling event based, at least in part, on a
specified condition defining the drilling event; responsive to a
determination that the specified condition defining the drilling
event is met, creating, via the channel data and the detected
drilling event, a new drilling-event data point for the
drilling-event data plot; populating the drilling-event data plot
with the new drilling-event data point as the new drilling-event
data point is created; and updating the provided real-time
cross-plot display with the populated drilling-performance data
plot and the populated drilling-event data plot.
20. The computer-program product of claim 19, the method
comprising, as the channel data is received: retrieving input data
comprising historical drilling-performance data for an offset well
relative to the current well, wherein the historical
drilling-performance data comprises a drilling event for the offset
well; updating the provided real-time cross-plot display with the
drilling event of the offset well; and responsive to determination
that a measured depth for the current well is within a
preconfigured distance of a depth at which the drilling event of
the offset well occurred, generating an alert.
Description
BACKGROUND
Technical Field
The present invention relates generally to drilling analytics and
more particularly, but not by way of limitation, to systems and
methods for enabling real-time drilling-performance analysis.
History of Related Art
Over the years, the world of drilling has become increasingly
technical. Drilling professionals constantly search for engineering
solutions to achieve profitable production targets efficiently.
Thus, the oil-and-gas industry continues to develop new
drilling-engineering techniques to facilitate the understanding of
geological and physical phenomena that occur during drilling
operations worldwide. However, it is difficult to present
information in a timely and comprehensive manner, for example, to a
drilling engineer, so that appropriate decisions can be made.
SUMMARY OF THE INVENTION
In one embodiment, a method includes, on a central computing system
comprising at least one server computer, facilitating a real-time
cross-plot display of drilling-performance data for a current well.
The real-time cross-plot display includes a plurality of data plots
represented on a common graph such that each data plot specifies at
least two drilling parameters. Each data plot comprises a plurality
of data points such that each data point is expressable as
Cartesian coordinates in terms of the at least two drilling
parameters. The method also includes the central computing system
receiving new channel data for the current well from a wellsite
computer system. In addition, the method includes the central
computing system creating, from the new channel data, new data
points for the plurality of data plots as the new channel data is
received. Furthermore, the method includes the central computing
system updating the plurality of data plots with the new data
points as the new data points are created.
In one embodiment, a system includes at least one server computer.
The at least one server computer is operable to perform a method.
The method includes facilitating a real-time cross-plot display of
drilling-performance data for a current well. The real-time
cross-plot display comprises a plurality of data plots represented
on a common graph such that each data plot specifying at least two
drilling parameters. Each data plot includes a plurality of data
points such that each data point is expressable as Cartesian
coordinates in terms of the at least two drilling parameters. The
method further includes receiving new channel data for the current
well from a wellsite computer system. In addition, the method
includes creating, from the new channel data, new data points for
the plurality of data plots as the new channel data is received.
Moreover, the method includes updating the plurality of data plots
with the new data points as the new data points are created.
In one embodiment, a computer-program product includes a
computer-usable medium having computer-readable program code
embodied therein. The computer-readable program code is adapted to
be executed to implement a method. The method includes facilitating
a real-time cross-plot display of drilling-performance data for a
current well. The real-time cross-plot display comprises a
plurality of data plots represented on a common graph such that
each data plot specifying at least two drilling parameters. Each
data plot includes a plurality of data points such that each data
point is expressable as Cartesian coordinates in terms of the at
least two drilling parameters. The method further includes
receiving new channel data for the current well from a wellsite
computer system. In addition, the method includes creating, from
the new channel data, new data points for the plurality of data
plots as the new channel data is received. Moreover, the method
includes updating the plurality of data plots with the new data
points as the new data points are created.
BRIEF DESCRIPTION OF THE DRAWINGS
A more complete understanding of the method and apparatus of the
present invention may be obtained by reference to the following
Detailed Description when taken in conjunction with the
accompanying Drawings wherein:
FIG. 1 illustrates a system for facilitating real-time
drilling-performance analysis;
FIG. 2 illustrates a process for performing real-time drilling
analysis;
FIG. 3 illustrates an example of real-time drilling-performance
analysis via a real-time display;
FIG. 4 illustrates a process for creating a cross plot;
FIG. 5 illustrates a process for updating a real-time cross-plot
display; and
FIGS. 6-7 illustrate examples of real-time cross-plot displays.
DETAILED DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS OF THE
INVENTION
In various embodiments, a real-time cross-plot display can
integrate a plurality of data plots that depict selected drilling
parameters and/or drilling events for a given well. In certain
embodiments, the real-time cross-plot display can be created when
drilling operations commence for a given well and be continuously
updated from that point forward.
For purposes of this patent application, drilling parameters can
include any type or segmentation of channel data, input data,
calculated data, and combinations thereof. For example, the
drilling parameters can relate to depth, date, densities,
geological formation, volume loss and gain, casing points, offset
well casing points, trajectory analysis (e.g., inclination,
azimuth, etc.), fluid properties (plastic viscosity, yield point,
etc.), standard pipe pressure (SPP), rate of penetration (ROP),
equivalent circulating density (ECD), gallons per minute (GPM),
weight on bit (WOB), torque, hook load, and/or the like. In
addition, trapping, drag, friction, resistance, and technical
comments can be integrated while drilling advances meter by meter,
thereby allowing simultaneous identification of a drilling
technical condition that is different from what is expected (e.g.,
a drilling event). In a typical embodiment, drilling-performance
cross plots can be shown in real-time on a real-time display (i.e.,
a real-time cross-plot display).
In various embodiments, cross-plots can be defined and used as
needed for a given well. In these embodiments, each cross plot can
include a selection of drilling parameters and drilling events, a
defined presentation format, and a defined period of time (e.g.,
from a time when drilling begins). The presentation format can
specify, for example, how and where the drilling parameters and
drilling events are graphically presented. In addition, in various
embodiments, a drilling professional such as, for example, a
drilling engineer, can create a custom cross-plot by selecting
drilling parameters and drilling events and specifying a
presentation format.
In addition, in various embodiments, real-time drilling-performance
analytics such as, for example, pore pressure and fracture
gradient, can be facilitated by leveraging historical
drilling-performance data from offset wells. As one of ordinary
skill in the art will appreciate, an offset well is a pre-existing
well that is in close proximity to the current well. For example,
an offset well can be located adjacently to the current well
according to spacing rules defined by applicable law. However, it
should be appreciated that immediate adjacency need not be
required.
FIG. 1 illustrates a system 100 for facilitating real-time
drilling-performance analysis. The system 100 includes a wellsite
computer system 102, a central computing system 108, and a
communications network 106. The wellsite computer system 102
includes a collection server 120, a remote-integration server 122,
and a network link 124. The central computing system 108 includes a
main server 110, a repository server 112, and a network link 126.
It should be appreciated that the depicted configurations of the
central computing system 108 and the wellsite computer system 102
are illustrative in nature. The central computing system 108 and
the wellsite computer system can each include any number of
physical or virtual server computers and databases. For example, in
various embodiments, the remote-integration server 122 may be
omitted or have its functionality integrated into the collection
server 120. Other modifications and rearrangements will be apparent
to one of ordinary skill in the art after reviewing inventive
principles contained herein.
In a typical embodiment, the wellsite computer system 102 is
located at or near a wellsite for a current well and communicates
with the central computing system 108 over the communications
network 106. The communications network 106 may include, for
example, satellite communication between the network link 124 of
the wellsite computer system 102 and the network link 126 of the
central computing system 108. Thus, the network link 124 and the
network link 126 can be, for example, satellite links. For
simplicity of description, communication between the wellsite
computer system 102 and the central computing system 108 may be
described below without specific reference to the network link 124,
the network link 126, and the communications network 106.
Using, for example, logging while drilling (LWD), the collection
server 120 receives and/or generates channel data 104 (e.g., in
WITS0) via data received from sensors that are in use at the
wellsite. A given sensor or other source of data is referred to
herein as a "channel." Data from a channel may be referred to as
"channel data," which term is inclusive of both raw data and
metadata. The raw data includes, for example, measured data
determined by the sensor or source. The measured data can include,
for example, resistivity, porosity, permeability, density, and
gamma-ray data. The metadata includes information about the raw
data such as, for example, time, depth, identification information
for the channel, and the like. The collection server 120 transmits
the channel data 104 to the remote-integration server 122, which
communicates the channel data 104 to the central computing system
108 in real-time.
On the central computing system 108, the main server 110 receives
the channel data 104 from the wellsite computer system 102 and
converts the channel data 104 to a common data format. The
conversion of channel data to a common data format is described in
detail in U.S. patent application Ser. No. 13/829,590, which
application is hereby incorporated by reference. As shown, the main
server 110 has a calculation engine 128 resident thereon. Via the
calculation engine 128, the main server 110 generates calculated
data in real-time based on the channel data 104. The calculation
engine 128 can be, for example, a software application that
implements algorithms to generate the calculated data. Based on
gamma-ray and resistivity data and other input data described with
respect to FIG. 3, the calculated data can include, for example,
pore pressure and a fracture gradient.
The calculation engine 128 can also maintain settings that are
utilized for generating the calculated data. For example,
implementation of Eaton and/or Mathews-and-Kelly algorithms may
require certain parameters such as an Eaton exponent, a matrix
stress coefficient, and a Poisson ratio. In a typical embodiment,
the settings maintained on the main server 110 specify values for
such parameters. If the value to be used for a given parameter is
not constant across all wells (e.g. varying based on geography or
well-specific data), the settings further specify rules for
selecting or calculating the value, as applicable. The settings
permit the calculation engine 128 to acquire necessary parameters
without the need for individual configuration for each well.
The repository server 112 stores and maintains the channel data 104
and any calculated data according to the common data format.
Storage and maintenance of data according to the common data format
is described in detail in U.S. patent application Ser. No.
13/829,590, which application is incorporated by reference above.
In a typical embodiment, the repository server 112 stores channel
data from a plurality of wellsite computer systems located at a
plurality of wellsites in this fashion. In addition, the repository
server 112 typically maintains historical drilling-performance data
(e.g., channel data, calculated data, etc.) for offset wells
relative to the current well.
The repository server 112 facilitates a real-time display 114 of
drilling-performance data related to the wellsite. In a typical
embodiment, the real-time display 114 is provided via a network
such as, for example, the Internet, via a web interface. The
real-time display 114 is typically shown and updated in real time
on a computing device 116 as the channel data 104 is received. For
example, in certain embodiments, the real-time display 114 can
include gamma-ray and resistivity data for a formation being
drilled. An example of these embodiments will be described with
respect to FIGS. 2 and 3. As described with respect to FIGS. 2 and
3, the real-time display 114 can allow engineering personnel 118 to
perform real-time drilling analysis for the wellsite.
By way of further example, in various embodiments, the real-time
display 114 can be a real-time cross-plot display. In these
embodiments, the real-time display 114 is operable to show, on a
common graph, a cross-plot that integrates a plurality of data
plots. The cross-plot generally includes at least one horizontal
axis and at least one vertical axis. Each data plot of the
cross-plot generally specifies at least two drilling parameters
such that one drilling parameter is associated with a horizontal
axis of the cross-plot and one drilling parameter is associated
with a vertical axis of the cross-plot. In that way, each data plot
represents a set of data points that can be expressed, for example,
as Cartesian coordinates in terms of the at least two drilling
parameters.
For example, if a given data plot specifies fluid gain/loss and
time as the at least two drilling parameters, data points of the
given data plot could be expressed as Cartesian coordinates in
terms of a fluid gain/loss value and a time (e.g., day, time, hour)
at which the fluid gain/loss value was collected. It should be
appreciated that the cross-plot can include more than one
horizontal axis and/or more than one vertical axis. In various
embodiments, the inclusion of multiple horizontal axes and/or
multiple vertical axes further facilitates the presentation of
disparate drilling-performance data. Examples of a real-time
cross-plot display will be described with respect to FIGS. 4-7.
For purposes of illustration, examples of equations that can be
used to compute calculated data will now be described. In some
embodiments, pore pressure (Pp) can be computed using the Eaton
method as embodied in Equation 1 below, where S represents stress
(i.e. pressure exerted by the weight of the rocks and contained
fluids thereabove in units of, e.g., g/cc), PPN represents normal
pore pressure according to a hydrostatic gradient, Ro represents
observed resistivity, Rn represents normal resistivity, and x
represents an Eaton exponent.
.times..times..times. ##EQU00001##
For purposes of this example, S, PPN, Ro, and Rn are input data for
calculating pore pressure. In particular, S and Ro are examples of
parameters that can be provided by channel data for the current
well. The Eaton exponent (x) is an example of a parameter that can
be retrieved from settings maintained by the calculation engine 128
of FIG. 1. In some embodiments, PPN can also be retrieved from
settings maintained by the calculation engine 128. In a typical
embodiment, Rn is obtained using historical drilling-performance
data for an offset well. In this fashion, pore pressure for the
current well can be calculated in real-time by retrieving
resistivity data for the offset well. A specific example will be
described with respect to FIG. 3.
In various embodiments, a fracture gradient (Fg) can be computed
using the Eaton method as embodied in Equation 2 below, where Pp
and S represent pore pressure and stress, respectively, as
described above and v represents a Poisson ratio.
.times..times..times. ##EQU00002##
For purposes of the example of Equation 2, stress (S), pore
pressure (Pp) and the Poisson ratio (v) are input data for
calculating a fracture gradient for a current well. Pp can be
computed as described with respect to Equation 1 above. Stress (S)
can also be obtained as described with respect to Equation 1. The
Poisson ratio (v) is an example of an input value that can be
retrieved from settings maintained by the calculation engine 128 as
described with respect to FIG. 1.
In various embodiments, a fracture gradient (Fg) can also be
computed using the Matthews and Kelly method as embodied in
Equation 3 below, where Pp and S represent pore pressure and
stress, respectively, as described above and .kappa..sub.i
represents a matrix stress coefficient. Fg=Pp+(S-Pp).kappa..sub.i
Equation 3
For purposes of the example of Equation 3, stress (S), pore
pressure (P) and the matrix stress coefficient (.kappa..sub.i) are
input data for calculating a fracture gradient for a current well.
The pore pressure (Pp) and stress (S) can be obtained as described
with respect to Equation 2. .kappa..sub.i is an example of an input
value that can be retrieved from settings maintained by the
calculation engine 128 as described with respect to FIG. 1.
FIG. 2 illustrates a process 200 for performing real-time drilling
analysis using the system 100 of FIG. 1. At step 202, the wellsite
computer system 102 collects the channel data 104 in real-time from
sensors via, for example, LWD. The channel data 104 is received in
an initial data format such as, for example, WITS0. From step 202,
the process 200 proceeds to step 204. At step 204, the wellsite
computer system 102 transmits the channel data 104 to the central
computing system 108 via the communications network 106. From step
204, the process 200 proceeds to step 206. At step 206, the central
computing system 108 receives the channel data from the wellsite
computer system 102. From step 206, the process 200 proceeds to
step 208.
At step 208, the central computing system 108 converts the channel
data 104 to a common data format. From step 208, the process 200
proceeds to step 210. At step 210, the channel data 104 is stored
on the central computing system 108 according to the common data
format. From step 210, the process 200 proceeds to step 212. At
step 212, the calculation engine 128 generates calculated data
based on the channel data 104, settings, and other input data
described with respect to FIG. 3. As described above, the
calculation engine 128 may be, for example, a software application
that implements algorithms to generate the calculated data. From
step 212, the process 200 proceeds to step 214.
At step 214, the central computing system 108 stores the calculated
data. For example, the calculated data can be stored on the
repository server 112. From step 214, the process 200 proceeds to
step 216. At step 216, the central computing system 108 updates the
real-time display 114 to include selected data such as, for
example, all or part of the channel data 104 and all or part of the
calculated data. Examples of the real-time display 114 will be
described in greater detail with respect to FIGS. 3-7. From step
216, the process 200 proceeds to step 218. At step 218, the process
200 ends.
FIG. 3 illustrates an example of real-time drilling-performance
analysis via a real-time display 314. To facilitate comparative
analysis, for example, by a drilling engineer, the real-time
display 314 depicts drilling-performance data for both a current
well 340 and an offset well 342 relative to true vertical depth
(TVD). In a typical embodiment, the offset well 342 is pre-selected
and associated with the current well 340 due to its geographic
proximity to the current well 340. In various embodiments, the
pre-selection can be made by drilling personnel such as a drilling
engineer and stored by a repository server such as the repository
server 112 of FIG. 1.
The drilling-performance data depicted by the real-time display 314
can include, inter alia, selected channel data, input data,
calculated data, casing-point data, and event data. The selected
channel data includes, for example, channel data from a well site
that is received at a central computing system, converted to a
common data format, and stored as described with respect to FIGS. 1
and 2. The input data is additional data that is received, for
example, from a drilling engineer or from other data stored within
a repository such as a repository maintained by the repository
server 112 of FIG. 1. The calculated data is data that is
calculated, for example, by a calculation engine such as the
calculation engine 128 of FIG. 1. The casing-point data includes
information related to the placement and size of casing utilized in
a given well. The event data is data related to certain detected
events at a well such as, for example, a stuck pipe, lost
circulation, or a kick (i.e., undesired influx of formation fluid
into the wellbore).
With respect to the current well 340, the real-time display 314
shows selected channel data, input data, calculated data, and
casing-point data. In particular, the selected channel data for the
current well 340 includes gamma-ray data 320(1), resistivity data
324(1), lithography 328(1), and fluid density 332(1). The input
data for the current well 340 includes gamma-ray trend lines 322(1)
(also referred to herein as shale lines) and a resistivity-trend
line 326(1) (also referred to herein as a normal compaction trend).
The calculated data for the current well 340 includes pore pressure
330(1) and fracture gradient 334(1). The casing-point data includes
one or more casing points 336(1) (which are updated in real
time).
With respect to the offset well 342, the real-time display 314
shows selected channel data, input data, calculated data,
casing-point data, and event data. It should be appreciated that
all such data for the offset well 342 is generally historical
drilling-performance data (as opposed to real-time data for the
current well 340). In particular, the selected channel data for the
offset well 342 includes gamma-ray data 320(2), resistivity data
324(2), lithography 328(2), and fluid density 332(2). The input
data for the offset well 342 includes gamma-ray trend lines 322(2)
(also referred to herein as shale lines) and a resistivity-trend
line 326(2) (also referred to herein as a normal compaction trend).
The calculated data for the current well 340 includes pore pressure
330(2) and fracture gradient 334(2). The casing-point data includes
one or more casing points 336(2). The event data for the offset
well 342 includes one or more drilling events 338.
With respect to the current well 340, acquisition of the input data
will now be described. As mentioned above, the selected channel
data for the current well 340 is displayed and refreshed in
real-time as such data is received by a central computing system
such as, for example, the central computing system 108 of FIG. 1.
As the selected channel data is received, the central computing
system 108 gathers the input data, i.e., the gamma-ray trend lines
322(1) and the resistivity-trend line 326(1). In a typical
embodiment, the gamma-ray trend lines 322(1) are traced by drilling
personnel such as, for example, a drilling, geological or
geophysical engineer, who determines points of shale. Shale, as one
of ordinary skill in the art will appreciate, generally emit more
gamma rays than other sedimentary rocks. The gamma-ray trend lines
322(1) generally connect points of shale and represent an average
of the gamma-ray data 320(1) between those shale points (i.e.
spanning that trend line). For example, in various embodiments, a
drilling engineer may be prompted at configurable points in time to
trace the gamma-ray trend lines.
The resistivity-trend line 326(1) is typically acquired
automatically from historical drilling-performance data for the
offset well 342. In that way, the resistivity-trend line 326(2)
(i.e., the normal compaction trend for the offset well 342) serves
as the resistivity-trend line 326(1). The resistivity-trend line
326(2) is a normalization of the resistivity data 324 for the
offset well 342.
The calculated data for the current well 340 is generated by a
central computing system such as, for example, the central
computing system 108 of FIG. 1, based on the selected channel data
and the input data for the current well 340. In a typical
embodiment, the calculated data for the current well 340 has
defined relationships, established on the central computing system
108 of FIG. 1, with the selected channel data and the input data.
Particularly, the gamma-ray data 320(1), the gamma-ray trend lines
322(1), the resistivity data 324(1), and the resistivity-trend line
326(1) are leveraged by a calculation engine such as, for example,
the calculation engine 128, to compute the pore pressure 330(1) and
the fracture gradient 334(1) in real time. In that way, published
algorithms such as those developed by Eaton and Matthews and Kelly
may be used in real time to compute the pore pressure 330(1) and
the fracture gradient 334(1).
Moreover, the real-time display 314 also enables other types of
real-time drilling-performance analyses. As one example of
real-time drilling-performance analysis, the real-time display 314
enables drilling personnel such as, for example, drilling
engineers, to perform real-time geopressure analysis. Drilling
engineers are able to compare the pore pressure 330(1) and the
fracture gradient 334(1) for the current well 340 with the pore
pressure 330(2) and the fracture gradient 334(2) for the offset
well. This real-time geopressure analysis allows drilling engineers
to compare trends and anticipate changes based on the offset well
342. The geopressure analysis can also be correlated with the one
or more drilling events 338, as described further below.
Further real-time drilling-performance analysis is enabled by the
one or more drilling events 338. Each of the one or more drilling
events 338 is typically plotted at a depth at which a defined
adverse drilling event occurred in the offset well 342. The one or
more drilling events 338 can include, for example, stuck pipes,
lost circulation, kicks, and the like. As a result of the
geographic proximity between the current well 340 and the offset
well 342, circumstances that led to the one or more drilling events
338 are often likely to reoccur at similar depths in the current
well 340. Therefore, the real-time display 314 allows drilling
personnel to anticipate and plan for the one or more drilling
events 338. In a typical embodiment, when the depth of the current
well 340 is within a preconfigured distance of the depth at which
one of the one or more drilling events 338 occurred (e.g., 500
feet), an alert is generated and presented to responsible
personnel. The alert can be, for example, a beep or alarm.
Responsive to the alert, the responsible personnel may perform, for
example, the real-time geopressure analysis described above so that
it can be determined if the pore pressure 330(1) is trending
similarly to the pore pressure 330(2). Corrective action such as an
adjustment in the fluid density 332(1) may be taken.
As another example of real-time drilling-performance analysis, the
real-time display 314 further enables casing-point prediction. As
described above, the real-time display 314 shows the one or more
casing points 336(1) for the current well 340 and the one or more
casing points 336(2) for the offset well 342. Using data from the
one or more casing points 336(2), drilling personnel are able to
predict both size and placement for future casing points for the
current well 340.
A further example of real-time drilling-performance analysis
enabled by the real-time display 314 relates to density analysis.
As described above, the real-time display 314 displays both the
fluid density 332(1) for the current well 340 and the fluid density
332(2) for the offset well 342. By reviewing and comparing density
trends, drilling personnel such as, for example, drilling
engineers, are able to determine if the fluid density 332(1) for
the current well 340 should be increased, decreased, or
maintained.
In a typical embodiment, the real-time display 314 can be
customized based on the desires of drilling engineers. For example,
the selected channel data can include more, less, or different
channel data than described above. Likewise, the calculated data
can have defined relationships with other channel data and/or input
data for purposes of performing different calculations in real
time.
FIG. 4 illustrates a process 400 for creating a cross plot using
the system 100 of FIG. 1. At step 402, the central computing system
108 receives a selection of one or more wells from a user such as,
for example, a drilling engineer. In a typical embodiment, the
selection is of a current well (e.g., a well that is being
drilled). From step 402, the process 400 proceeds to step 404.
At step 404, the central computing system 108 receives a selection
of a plurality of data plots for the current well from the user.
Each data plot generally specifies at least two drilling parameters
such that one drilling parameter can be associated with a
horizontal axis and one drilling parameter can be associated with a
vertical axis. The at least two drilling parameters can correspond,
for example, to depth, date, densities, geological formation,
volume loss and gain, casing points, calculated data (e.g. pore
pressure), input data, etc.
In some cases, a given data plot of the plurality of data plots can
be a drilling-event data plot. The drilling-event data plot can
correspond to one or more types of drilling events such as, for
example, the one or more drilling events 338 of FIG. 3. The one or
more drilling events can include, for example, stuck pipes, lost
circulation, kicks, and the like. The at least two drilling
parameters of the drilling-event data plot can include any of the
drilling parameters described above. However, the drilling-event
data plot will generally only include data points when, for
example, a specified Boolean condition defining the event is met
(e.g., stuck pipe, lost circulation, kicks, etc.). The one or more
drilling events can be actual events that have been detected via
new channel data for the current well. The one or more drilling
events can also be historical drilling events for an offset well
that are plotted, for example, at a depth at which such event
occurred in the offset well. In that way, the one or more drilling
events can facilitate alerting as described with respect to FIG. 3.
From step 404, the process 400 proceeds to step 406.
At step 406, the central computing system 108 maps each data plot
to data sources for the current well. As described above, each of
the plurality of data plots generally specifies at least two
drilling parameters. The mapping can include specifying which data
fields form the basis for each drilling parameter. The drilling
parameters may directly correspond to particular fields of channel
data, calculated data, and/or the like. In that way, when, for
example, new channel data for a current well is received, the
central computing system 108 can at that time create new data
points for the plurality of data plots. In some embodiments, the
step 406 may be omitted when, for example, all drilling parameters
are pre-mapped to channel data prior to the user's selection of the
plurality of data plots. From step 406, the process 400 proceeds to
step 408.
At step 408, the central computing system 108 defines a
presentation format for the cross plot. In a typical embodiment,
the presentation format encompasses specification of, for example,
measurement units, data precision/scaling of the cross-plot,
presentation attributes (e.g., color, layout, etc.), and/or the
like. In various embodiments, the presentation format can be
defined responsive to manual configuration by the user, technical
personnel acting at the instruction of the user, and/or the like.
The presentation format can also be defined based on pre-existing
templates. It should be appreciated that different ones of the
plurality of data plots may share a drilling parameter (e.g.,
time). In such cases, certain ones of the plurality of data plots
may share an axis of the cross-plot. From step 408, the process 400
proceeds to step 410.
At step 410, the central computing system 108 populates the
plurality of data plots with data points for the current well. From
step 410, the process 400 proceeds to step 412. At step 412, the
central computing system facilitates a real-time cross-plot display
of the cross-plot in a fashion similar to that described above with
respect to FIG. 2. The real-time cross-plot display can be viewed,
for example, by a drilling engineer. In various embodiments, the
real-time cross-plot display can be updated with technical comments
of a user such as, for example, the drilling engineer. The
technical comments can include drilling analysis of the user, be
inserted at an appropriate place on the cross-plot, and be
persistently stored as part of the cross-plot. The technical
comments can then be viewed by whomever accesses the real-time
cross-plot display. After step 412, the process 400 ends.
FIG. 5 illustrates a process 500 for updating a real-time
cross-plot display using the system 100 of FIG. 1. The real-time
cross-plot display includes a plurality of data plots and can be
created, for example, as described with respect to FIG. 4. The
process 500 begins at step 502. At step 502, the central computing
system 108 creates new data points for the plurality of data plots.
The new data points can be based on channel data, calculated data,
and/or input data as described above. From step 502, the process
500 proceeds to step 504. At step 504, the central computing system
108 populates the plurality of data plots with the new data points.
From step 504, the process 500 proceeds to step 506. At step 506,
the central computing system 108 updates/refreshes the real-time
cross-plot display. After step 506, the process 500 ends.
FIGS. 6-7 illustrate examples of real-time cross-plot displays. The
real-time cross-plot displays of FIGS. 6-7 can be created as
described with respect to FIG. 4. In various embodiments, the
real-time cross-plot displays of FIGS. 6-7 can also be updated in
real-time as described with respect to FIGS. 2 and 5.
Real-time drilling performance analyses such as those described
above allow drilling personnel such as, for example, drilling,
geological, or geophysical engineers, to reduce non-productive time
(NPT). Alerts, recommendations, and real-time displays such as
those described above allow drilling personnel to perform better
analyses more quickly and more efficiently using, for example, a
single systematic slide provided by a real-time cross-plot display.
The automation provided by a system such as, for example, the
system 100 of FIG. 1, frees drilling personnel from manually
gathering information necessary to analyze and make decisions
regarding the drilling performance of a well. For example, in
various embodiments, real-time cross-plot displays such as those
described above can allow establishment of historical and
comparatives analysis for different phases along a given well such
as: 171/2'', 121/4'', 81/2'', 61/2'' and 5''. Therefore, real-time
cross-plot displays can be tailored to the objective of the well.
Thus, technical analyses and risk detections can be performed in a
timely manner and the drilling process can be optimized.
Although various embodiments of the method and apparatus of the
present invention have been illustrated in the accompanying
Drawings and described in the foregoing Detailed Description, it
will be understood that the invention is not limited to the
embodiments disclosed, but is capable of numerous rearrangements,
modifications and substitutions without departing from the spirit
of the invention as set forth herein.
* * * * *